# US 2014/0151047 A1 · Method for Hydraulically Fracturing a Well Using A Frac Water Heater > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 2014/0151047 A1 - Document ID: US20140151047A1 - Status: Published application - Kind: A1 - Application number: 14/092,462 - Filed: 2013-11-27 - Published: 2014-06-05 - Earliest claimed: 2008-07-07 - Inventors: Ronald L. Chandler - Web page: https://patentgrep.com/patent/US20140151047A1 ## CPC - E21B 43/267: reinforcing fractures by propping - E21B 43/2405: {in association with fracturing or crevice forming processes (E21B43/247 takes precedence)} - E21B 43/2607: {Surface equipment specially adapted for fracturing operations} - F24H 1/009: {for vehicle systems} - F24H 1/06: Portable or mobile, e.g. collapsible - F24H 1/08: Packaged or self-contained boilers, i.e. water heaters with control devices and pump in a single unit - F24H 1/40: with water tube or tubes - F24H 9/2035: {using fluid fuel} - F24H 15/174: Supplying heated water with desired temperature or desired range of temperature - F24H 15/219: after heating - F24H 15/31: of valves having only one inlet port and one outlet port, e.g. flow rate regulating valves - F28D 7/0066: {Multi-circuit heat-exchangers, e.g. integrating different heat exchange sections in the same unit or heat-exchangers for more than two fluids (F28D7/103 takes precedence)} - F28D 7/02: the conduits being helically coiled (F28D7/10 takes precedence {F28D7/0016 and F28D7/0033 take precedence}) - F28D 7/08: the conduits being otherwise bent, e.g. in a serpentine or zig-zag (F28D7/10 takes precedence){(F28D7/0016 and F28D7/0033 take precedence)} - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS - F24H: FLUID HEATERS, e.g. WATER OR AIR HEATERS, HAVING HEAT-GENERATING MEANS, e.g. HEAT PUMPS, IN GENERAL (steam generation F22) - F28D: HEAT-EXCHANGE APPARATUS, NOT PROVIDED FOR IN ANOTHER SUBCLASS, IN WHICH THE HEAT-EXCHANGE MEDIA DO NOT COME INTO DIRECT CONTACT (fluid heaters having heat generating means and heat transferring means F24H; furnaces F27; details of heat-exchange apparatus of general) ## Abstract The present invention overcomes many of the disadvantages of prior art mobile oil field heat exchange systems by providing a portable heat exchange system. The present invention is a self-contained unit which is easily transported to remote locations. The present invention includes a single-pass tubular coil heat exchanger contained within a closed-bottom firebox having a forced-air combustion and cooling system. The rig also includes integral fuel tanks, hydraulic and pneumatic systems for operating the rig at remote operations in all weather environments. In a preferred embodiment, the portable heat exchanger system is used to heat water on-the-fly (i.e., directly from the supply source to the well head) to complete hydraulic fracturing operations. The present invention also includes systems for regulating and adjusting the fuel/air mixture within the firebox to maximize the combustion efficiency. The system includes a novel hood opening mechanism attached to the exhaust stack of the firebox. ## Claims ### Claim 1 A method of fracturing a subterranean formation at a remote work site to produce at least one of oil and gas, comprising the steps of: a) providing a portable heating system for heating treatment fluid, said heating system comprising a heat exchanger having a tubular coil featuring a single inlet and a single outlet; b) drawing treatment fluid from a fluid source to said inlet of said heat exchanger in said portable heating system; c) pumping said treatment fluid through a single pass of said heat exchanger in said portable heating system; d) heating said treatment fluid during said single pass through said heat exchanger by combusting an air-fuel mixture in said firebox using a plurality of burner assemblies; e) directing the heated treatment fluid from said outlet of said heat exchanger directly to a well head at said work site for injection into the formation. ### Claim 2 (depends on 1) The method of claim 1, wherein said treatment fluid flows substantially continuously from said inlet to the outlet to the well head during the fracturing process. ### Claim 3 (depends on 2) The method of claim 2, wherein said treatment fluid flows at a substantially constant volumetric rate from said inlet to the outlet to the well head during the fracturing process. ### Claim 4 (depends on 1) The method of claim 1, wherein step e) further comprises adding chemical additives to the heated treatment fluid prior to injection into the formation. ### Claim 5 (depends on 4) The method of claim 4, wherein said chemical additives comprise friction reducer polymers, which reduce the viscosity of the heated treatment fluid. ### Claim 6 (depends on 1) The method of claim 1, wherein step e) further comprises adding proppants to the heated treatment fluid prior to injection into the formation. ### Claim 7 (depends on 6) The method of claim 6, wherein step e) further comprises adding a cross-linked guar gel. ### Claim 8 (depends on 1) The method of claim 1, wherein step e) further comprises adding chemical additives and proppants to the heated treatment fluid prior to injection into the formation. ### Claim 9 (depends on 8) The method of claim 8, wherein step e) further comprises adding a cross-linked guar gel. ### Claim 10 (depends on 1) The method of claim 1, wherein said treatment fluid is heated to at least 70° F. while pumping through said heat exchanger at a volumetric flow rate of at least 200 gpm. ### Claim 11 (depends on 10) The method of claim 10, wherein said treatment fluid is heated to between 70° F.-210° F. while pumping through said heat exchanger at a volumetric flow rate of at least 200 gpm. ### Claim 12 (depends on 1) The method of claim 1, wherein said treatment fluid is heated to at least 40° F. in ambient atmospheric temperatures below 25° F. while pumping through said heat exchanger at a volumetric flow rate ranging from at least 200 gpm. ### Claim 13 (depends on 12) The method of claim 12, wherein said treatment fluid is heated to between 40° F.-210° F. in ambient atmospheric temperatures below 25° F. while pumping through said heat exchanger at a volumetric flow rate ranging from 200-250 gpm. ### Claim 14 (depends on 1) The method of claim 1, wherein the step of drawing treatment fluid from said fluid source includes activating a hydraulically-powered centrifugal fluid pump integral to said portable heating system and in fluid communication with and configured between said fluid source and said inlet of said heat exchanger in said portable heating system. ### Claim 15 (depends on 1) The method of claim 1, wherein said treatment fluid is water. ### Claim 16 (depends on 1) The method of claim 1, wherein the volumetric rate at which treatment fluid is drawn from said fluid source in step b) substantially equals the volumetric rate of heated treatment fluid that is directed from the outlet directly to the well head in step e). ### Claim 17 (depends on 1) The method of claim 1, wherein the volume of treatment fluid drawn from said fluid source in step b) is substantially equal to the volume of heated treatment fluid directed from the outlet directly to the well head in step b). ### Claim 18 (depends on 1) The method of claim 1, wherein the inlet of said portable heating system further comprises a manifold having one or more spigots for receiving supply hose in fluid communication with said fluid source. ### Claim 19 (depends on 1) The method of claim 1, wherein the outlet of said portable heating system further comprises a manifold having one or more spigots for connecting to supply hose in fluid communication with said well head.